Natural Gas

Natural gas is the Henry Hub Louisiana benchmark, traded on NYMEX in million-British-thermal-units (MMBtu). Unlike crude oil, natural gas is a regional market: US prices have decoupled from European TTF and Asian JKM benchmarks since the 2014 shale revolution and the 2022 Russia-Ukraine war. US natgas typically trades $2-$5 per MMBtu while European TTF can trade $20-$40+.

Why it matters: natural gas is the largest single fuel for US electricity generation (~40%) and a critical input for fertilizer, chemicals, and industrial heat. A sustained natgas spike above $5 raises industrial production costs across the manufacturing base and feeds into PPI. It is also the cleanest single read on weather extremes in the US Northeast, the largest consuming region. For 2026, natgas is structurally bullish because of LNG export expansion (Plaquemines, Corpus Christi Stage 3) and AI data center electricity demand growth.

In April 2026 US natural gas trades in the $3.50-$4.50/MMBtu range, well above the 2024 lows near $1.50 but below the 2022 peak of $9. The structural drivers are LNG export capacity (US is now the world's largest LNG exporter with capacity adding through 2027), AI data center electricity demand (datacenter peak load is doubling every 18-24 months in some Midwest grids), and producer discipline after the 2024 capex retrenchment.

The risk is mild weather: a warm winter or cool summer could collapse demand and pressure prices back toward $2.50. The bull case is sustained LNG bid plus a single cold-weather event. Natgas has the highest realized volatility of any major commodity because its storage is physical and seasonal and arbitrage to Europe is capped by liquefaction capacity.

Modern Henry Hub range: $2 in the 2015-2016 shale glut, $4-$6 in normal 2017-2021 conditions, $9 in August 2022 (Russia-driven LNG arbitrage), $1.50 in early 2024 (mild winter, oversupply), and $3.50-$4.50 in 2026. The three drivers are weather (heating-degree-days and cooling-degree-days), LNG export capacity utilization, and US storage levels (the EIA weekly storage report drives short-term moves of 5-10% routinely).

First, EIA weekly storage report (Thursdays at 10:30am ET). Surprises versus consensus drive 3-5% same-day moves.

Second, LNG export terminal utilization. Plaquemines and Corpus Christi Stage 3 ramps shift the demand curve permanently higher.

Third, 8-14 day weather forecasts. Most natgas trading is weather-driven on the margin; the NWS Climate Prediction Center outlooks frequently move the front-month contract.